Produced Water Borate Crosslinking Compositions and Method of Use

ABSTRACT

A composition and method for treating a fracturing fluid comprising produced water with high levels of dissolved solids using a polymer crosslinked with a boron compound and a high pH alkylamine buffer. The composition improves the viscosity stability of the fracturing fluid at elevated bottom-hole temperatures, particularly when the fluid has high levels of calcium and magnesium. The composition is particularly useful with polysaccharides, including galactomannan gums, such as guar gum, locust bean gum, and karaya gum, and allows for the use of the preferred boron compound crosslinkers in high total dissolved solids fracturing fluids without the pH destabilization problems encountered with the prior art.

BACKGROUND OF THE INVENTION

1. Field of the Invention

This invention relates to a composition and method for treating fluidshaving high levels of total dissolved solids, such as produced water,with a boron crosslinked polymer and pH buffer to improve thefunctionality and stability of the viscosity of the fluid for use in oiland gas operations, particularly in fracturing operations.

2. Description of Related Art

Large amounts of the world's oil and gas reserves are contained informations where extraction is more difficult. With increasing pricesfor oil and natural gas and the positive environmental aspects of itsuse as a fuel source, there is greater demand for technologies toefficiently extract and recover oil and natural gas from theseformations. One technique that has been developed to stimulateproduction in these formations is hydraulic fracturing. Using thistechnique, a fracturing fluid is pumped into a well under sufficientpressure to fracture the face of the mineral formation throughout theformation. Fracturing releases the hydrocarbon trapped within theformation and the hydrocarbon may then be extracted through the well. Asthe pressure on the face of the fractured mineral is released to allowfor the extraction of the hydrocarbon fuel, the fracture in theformation would normally close again. However, proppants, such as coursesand or sintered bauxite, are often added to the fracturing fluid tohold the fractures open, thereby increasing the effectiveness of thefracturing fluid. The fractures, held open by the proppants, form achannel through which the trapped hydrocarbons may escape after pressureis released thereby increasing oil and gas production.

Water from various sources is commonly used as the primary fluid infracturing fluids. The operations typically require large amounts ofwater, up to several million gallons per well, which may be suppliedfrom nearby fresh water ponds, lakes, rivers, fresh water subterraneanaquifers, etc. Ideally, produced waters (both ground water and recoveredinjected water) from existing wells in the area are used as a watersource to reduce water costs, recycle the produced waters that wouldotherwise be injected into a disposal well, and conserve fresh waterresources. There is generally an abundant amount of produced watersavailable since produced waters can make up to around 90% of the totalfluids produced per day in some wells. These water sources, andparticularly produced waters, typically contain high levels of totaldissolved solids (TDS), such as calcium, magnesium, chloride,bicarbonate, sulfate, iron, etc. According to the United StatesGeological Service National Produced Water Database, the TDS in producedwater varies from less than 1,000 mg/liter to 399,943 mg/liter (based onmore than 50,000 samples), depending on location. The TDS more commonlyranged from 10,000 to 100,000 mg/liter which comprised 42.3% of thesamples. 25.2% were within 100,000 to 200,000 TDS and 12.7% were greaterthan 200,000 TDS.

Polymeric thickening agents are typically added to the fracturing fluidto increase the viscosity of the fluid, which helps prevent leak-offinto the formation, decrease friction losses, and suspend and transportthe proppant materials. Galactomannan gums and derivatives thereof, suchas guar, HPG, CMHPG, and CMG are frequently used as the polymericthickening agent. When hydrated, these polymers form gels that increasethe viscosity of the fracturing fluid. Further increases in viscosityare achieved by crosslinking the polymer with a crosslinking agent.Boron, zirconium, and titanium compounds are common crosslinking agents.Crosslinking requires a certain pH level, depending on the polymer andcrosslinker used, in order to maintain the crosslinking between thecrosslinker and polymer.

Crosslinking with boron is generally preferred for guar polymers andsome guar derivatives, such as HPG; however, it can be difficult tomaintain the stable pH needed. For crosslinking with boron compounds,the guar gum polymer is first hydrated to form a gel under neutral oracidic conditions. The hydrated guar is then mixed with a boroncompound, such as boron salts or boric acid, and the pH elevated tocrosslink the hydrated guar and borate. The crosslinking will not occurat pH values less than about 8.0 and is preferably carried out at a pHabove 9.0. The crosslinking is also reversible if the pH drops belowthese levels.

Maintaining an adequate pH level to avoid reversal of the crosslinkingis a problem frequently encountered in fracturing operations. If thecrosslinking is reversed, the viscosity of the fracturing fluid willdecrease. Higher bottom hole temperatures are known to lower pH valuesand can cause degradation of the crosslinked polymer. Bottom holetemperatures in fracturing operations are normally greater than 80° F.,and can be greater than 250° F., which is high enough to adverselyimpact the pH and the viscosity of the fracturing fluid.

One way the prior art has addressed this problem is to increase theinitial loading of polymer. The use of up to 100 pounds of galactomannangum per 1,000 gallons of total fracturing fluid has been disclosed, withhigher amounts of gum required for higher temperatures and higher saltcontent, in order to maintain sufficient viscosity. This has thedrawback of increasing the costs of the fracturing operation, both inadded raw materials and in increased power requirements. Having a veryhigh initial viscosity requires greater horsepower to pump the fluidthrough the wellbore. Additionally, increasing the initial loading ofpolymer alone is not effective in maintaining a stable viscosity infracturing fluids with high TDS levels. Another way the prior art hasaddressed this problem is to add a pH buffer to the fracturing fluid asa stabilizer. However, many of these buffers will react with ions inhigh TDS fracturing fluids, making them ineffective for use inoperations where produced waters are used as a source of fracturingfluid.

Although boron crosslink guar fluids are generally preferred, they arenot normally used in fracturing fluids comprising high TDS producedwater because of the difficulty in elevating and maintaining a stable pH(9.0-12.0) required for crosslink stability at bottom hole temperatures.Potassium hydroxide, sodium hydroxide, ammonium hydroxide, potassiumcarbonate, and mixtures thereof are common pH buffers used with boroncrosslinked guar fluids in fracturing operations. While these pH buffersare usually sufficient to stabilize the fluid in fresh waters, thesebuffers react with the dissolved solids in high TDS fluids, particularlycalcium and magnesium. Produced waters can contain calcium and magnesiumlevels well in excess of 500 ppm and 150 ppm, respectively. At ambientand elevated temperatures in the range of 80° F. to 200° F. (or higher),like those bottom-hole temperatures found in fracturing operations, themagnesium and calcium ions combine with available hydroxide ions fromthe pH buffer to form magnesium or calcium hydroxides or carbonates,which precipitate out of solution. These and other precipitates areundesirable because they may adversely affect the permeability of theformation or cause damage to the equipment. This reaction also depletesthe pH buffer and results in the inability to sufficiently stabilize thepH at the necessary elevated level. Often erratic or unstable crosslinkfluids result.

Because of these issues, guar polymers and guar-derivative polymers arenot normally considered candidates for crosslinking with boron in highTDS fracturing fluids such as produced waters, and boron crosslinking isoften limited to water sources having less than 1,500 ppm totaldissolved solids particularly with calcium and magnesium levels lessthan 500 ppm and 150 ppm respectively (primarily fresh water sources).These guar and guar-derivative polymers are commonly crosslinked with azirconium crosslinker at a pH of about 7.5 or less where high TDSproduced waters or mixtures of produced and fresh waters are used as thefracturing fluid. Crosslinking with a zirconium crosslinker at higher pHvalues of 9.0 or greater is also possible with fracturing fluidscontaining greater amounts of fresh water and low TDS values. Somezirconium crosslinkers are thermally activated where crosslinking isachieved when the fluid temperature is elevated in transit to or atbottom-hole temperatures. Crosslinked bonds with zirconium are covalent(fixed) types bonds, so once crosslinked maintaining the pH level is notnormally critical to maintaining the crosslink. Crosslinked bonds withboron crosslinkers are normally ionic (reversible) type bonds, somaintaining the pH level for the duration of the treatment is criticalin order to maintain the crosslinking bond with guar polymer andguar-derivative polymers. Although boron crosslinkers require greater pHstability, they have some advantages over zirconium crosslinkers. Boroncrosslinkers are generally less expensive than zirconium crosslinkersand have the ability to re-crosslink (heal) after shear or when thecrosslink is broken by lowering the pH if the pH becomes elevated again,unlike zirconium crosslinks that are generally considered brittle and donot re-crosslink once broken. Boron crosslinks are also much lesssensitive to critical crosslinker and pH buffer chemical fluctuationsand hence more forgiving than zirconium crosslinks. For example, aslittle as 0.2 gpt excess zirconium crosslinker has been known to breakthe crosslink. Also, boron crosslinks are preferred for their ability tominimize post frac damage due to the ability to un-crosslink after thetreatment with the lowering of the fluid pH as the formation returns toits pH at equilibrium, which is normally considered to be less than 7.5.A breaker, which is commonly added to break the polymer strand to reducethe viscosity of the fracturing fluid when the fracturing operation iscomplete, can break the polymer strand more efficiently when the boroncrosslink has been reversed. The zirconium crosslink, lacking thisability, is maintained during and after the treatment due to its fixedcovalent bond. The breaker must react with both the stable crosslink andpolymer when a zirconium crosslinker is used and it is generally moredifficult to break.

SUMMARY OF THE INVENTION

This invention relates to a composition and method for treating producedwater with high levels of dissolved solids using a polymer crosslinkedwith a boron compound and a high pH alkylamine buffer. The compositionimproves the pH stability and maintains a stable crosslinked fracturingfluid at elevated bottom-hole temperatures, particularly when the fluidhas high levels of calcium and magnesium. Although the viscosity offracturing fluid can vary depending on the type and concentration ofpolymer, crosslinker, buffer, temperature, and concentrations of thevarious components added to the fracturing fluid, maintaining a stableelevated pH prevents the crosslinking bond between the boron compoundand the polymer from reversing, which aids in maintaining a sufficientlyhigh viscosity to transport proppants and control leak-off. Thecomposition is particularly useful with polysaccharides, includinggalactomannan gums, such as guar gum, locust bean gum, and karaya gum,or their derivatives and allows for the use of the preferred boroncompound crosslinkers in high TDS fracturing fluids without the pHdestabilization problems encountered with the prior art.

One preferred composition according to the invention comprises apolysaccharide (preferably a galactomannan gum polymer), a boroncompound crosslinker, and an alkylamine pH buffer (preferablydiethylenetriamine or its related compounds). According to anotherpreferred composition, the pH buffer may be any basic organic compoundcomprising amines, including akyl amines, aryl amines, poly amines, andcyclo amines, and may be primary, secondary, or tertiary amines, whereasthe basic compounds yield a pH greater than about 8.0 when dissolved inwater. Examples of such compounds include n-butylamine,diethylenetriamine (DETA), diaminobutane, diethyldiamine,diisopropylamine, dodecylamine, ethylamine, ethylenediamine,di-(gamma-aminopropylether), methyleneamine, piperazine,triethylenetetramine, tetraethylenepentamine, triethylamine, and aminodiols, glycols and poly glycols. Other compounds that yield a pH greaterthan about 8.0 when dissolved in water and comprise amines may also beused as will be understood by those of ordinary skill in the art.Another preferred composition according to the invention also comprisesa secondary pH buffer or pH modifier. The secondary pH buffer ormodifier is preferably a strongly alkaline hydroxide and/or carbonatecompound, such as potassium hydroxide, sodium hydroxide, ammoniumhydroxide, potassium carbonate, or mixtures thereof. These embodimentsof compositions according to the invention are added to fracturingfluids containing TDS levels in the range of about 1,500 ppm to 400,000ppm and preferably containing calcium levels in excess of about 500 ppmand/or magnesium levels in excess of about 150 ppm. These compositionsallow stable crosslinking of the polymer and the crosslinking agent athigh bottom hole temperatures in the range of about 80° F. to 250° F.,where prior art crosslinking usually fails, particularly in the presenceof high levels of hardness (from calcium, magnesium, and other dissolvedminerals) and particularly where guar or guar related polymers arecrosslinked with boron compounds.

According to a preferred embodiment for using a preferred compositionaccording to the invention, a polymer is first hydrated and added to thefracturing fluid, which contains water sources with TDS levels in therange of about 1,500 ppm to 400,000 ppm, such as produced waters ormixtures of produced waters and fresh waters. Then a crosslinking agent,amine pH buffer, and optionally a secondary pH buffer are added to thefracturing fluid containing the hydrated polymer. The crosslinking agentand amine pH buffer may be pre-mixed in a solution prior to adding tothe fracturing fluid, with a secondary pH buffer and/or additional aminepH buffer (which may further stabilize the crosslinked fluid) optionallyadded separately. Alternatively, the crosslinking agent and secondary pHbuffer may be pre-mixed in a solution prior to adding to the fracturingfluid, with the amine pH buffer added separately. As anotheralternative, the crosslinking agent, amine pH buffer, and secondary pHbuffer (if used) may all be added to the fracturing fluid separately.

When pre-mixed, the crosslinker-amine solution is added in aconcentration from 0.25 gpt (gallons per thousand gallons of fluid,including the fracturing fluid) to 30 gpt and more preferably from 1 gptto 10 gpt. When pre-mixed, the crosslinker-secondary buffer solution isadded in a concentration from about 0.25 gpt to 20 gpt, and morepreferably from about 1 gpt to 10 gpt. When the amine pH buffer isseparately added to the fracturing fluid with the crosslinker/buffersolution (either the crosslinker-secondary pH buffer solution or asadditional amine pH buffer added with the crosslinker-amine solution),preferably between 0.25 gpt to 30 gpt, and more preferably from 0.25 gptto 10 gpt, is used. When all of these compounds are added separately,preferably between about 0.41 ppt (pounds per thousand gallons of fluid,including the amount of fracturing fluid) to about 65.22 ppt, and mostpreferably about 3 ppt to about 11 ppt, of the crosslinking agent isused and about 0.25 gpt to about 20 gpt, and most preferably about 0.25gpt to about 10 gpt, of the secondary pH buffer is used (if desired).The concentrations of these compounds or solutions will vary dependingon the hardness of the water used in the fracturing fluid and thebottom-hole temperature.

BRIEF DESCRIPTION OF THE DRAWINGS

The composition of the invention is further described and explained inrelation to the following drawings wherein:

FIG. 1 is a graphical representation of the viscosity over time forseveral compositions tested.

FIG. 2 is a graphical representation of the viscosity over time forseveral compositions tested.

DESCRIPTION OF THE PREFERRED EMBODIMENTS

One preferred treatment composition according to the invention comprisesa boron-crosslinkable polysaccharide as the polymer, a boron compoundcrosslinker, and an amine high pH buffer. This preferred compositioncomprises about 5 to about 100 ppt (pounds per thousand gallons of totalfluid, including the fracturing fluid) polysaccharide, between about0.41 ppt to about 65.22 ppt, and most preferably about 3 ppt to about 11ppt, of the crosslinking agent, and about 0.25 gpt to 30 gpt amine pHbuffer.

The polysaccharide is preferably in a slurry with a hydrocarbon base,containing about 3-5 pounds of polysaccharide per one gallon of theslurry. The preferred polymer is a galactomannan gum, with guar gumbeing the most preferred polymer, but other hydratable water-solublepolymer solutions suitable for use in creating a crosslinked fracturingfluids, and particularly any of the hydratable polysaccharides that arecapable of gelling water based fluids may be used. Suitable polymers aregalactomannan gums, guars, locust bean gum, tara gum, karaya gum, cassiagum, hydroxypropyl guar, carboxymethyl guar, carboxymethylhydroxypropylguar, carboxymethyl hydroxyethylcellulose, carboxymethylcellulose,carboxymethyl hydroxyethyl cellulose and hydroxyethyl cellulose, andother derivatized guars and cellulose derivatives, and polyvinylalcohol. The polymer is hydrated with water in the fracturing fluid toform a viscosified or gelled fluid.

The preferred boron compound crosslinker is boric acid, but other boroncontaining compounds such as borax, sodium borate, disodium tetraborate,sodium tetraborate, sodium tetraborate decahydrate, amino boric acid,elluite, ulexite, colemanite, probertite, and mixes thereof may be used.Additionally, other non-boron crosslinking agents may be used, but thecombination of sufficient viscosity and improved stability achieved withboron compound crosslinkers makes them particularly suitable for use incompositions according to the invention. DETA is the preferred amine pHbuffer, but other alkylamines may also be used alone or may be used incombination with DETA. Other basic organic compounds comprising amines(including akyl amines, aryl amines, poly amines, and cyclo amines, andmay be primary, secondary, or tertiary amines) may also be used as anamine high pH buffer. These basic compounds yield a pH greater thanabout 8.0 when dissolved in water, preferably greater than about 10.0,and most preferably yield a pH in the range of 12-13. Examples of suchcompounds include n-butylamine, diethylenetriamine (DETA),diaminobutane, diethyldiamine, diisopropylamine, dodecylamine,ethylamine, ethylenediamine, di-(gamma-aminopropylether),methyleneamine, piperazine, triethylenetetramine,tetraethylenepentamine, triethylamine, and amino diols, glycols and polyglycols. These basic compounds comprising amines do not have thehydroxide or carbonate radicals common in most high pH buffers (such assodium hydroxide or potassium carbonate) which precipitate with highlevels of hardness (such as calcium and magnesium), thereby reducing thebuffering effect. The reaction of the preferred amine pH buffer, DETA,with magnesium and calcium is minimal. As such, the use of these aminepH buffers, such as DETA, are useful in mitigating precipitatingreactions with water hardness, such as calcium and magnesium, and aremore effective in maintaining a stable pH in high hardness or high TDSwaters such as hard fresh waters, produced waters and mixtures thereof.

According to another embodiment, the composition also comprises asecondary alkaline pH buffer or pH modifier. The secondary pH buffer ormodifier is preferably a strongly alkaline hydroxide and/or carbonatecompound, such as potassium hydroxide, sodium hydroxide, ammoniumhydroxide, potassium carbonate, or mixtures thereof. Although someprecipitation may occur when using such secondary pH buffers with highTDS, and particularly high calcium and magnesium levels, the addition ofthe amine pH buffer may inhibit the reaction that results in theprecipitation. The addition of a secondary pH buffer is optional and isnot required. When added to the fracturing fluid, the compositionaccording to this embodiment preferably comprises about 4.0 to about 6.0gpt polysaccharide slurry (containing about 3-5 lbs. of polymer pergallon of slurry), about 1.5 to about 4.0 gpt crosslinkingagent-secondary pH buffer solution, and about 0.5 to about 5.0 gpt aminepH buffer.

Other additives typically used in fracturing fluids, such as biocides,breakers, clay control additives, scale inhibitors, surfactants, waterrecovery agents, polymer hydration enhancers, high temperature gelstabilizers such as sodium and or ammonium thiosulfate, etc., andproppants may also be used. It is preferred to use 0.1-2.0 gpt biocideand 0.04 to 0.06 gpt low pH buffer (an 80% acetic acid solution ispreferred) with the compositions according to the invention. Theaddition of an acidic low pH buffer may aid in hydration of the polymer,which occurs best at neutral to acidic conditions, so it is preferred toadd the low pH buffer with, or near the same time as, the polymer.Although the amount of low pH buffer added is typically not enough tosignificantly drop the pH level of the fluid, in the tests discussedbelow, the 80% acetic acid solution was added with the biocide, polymer(a guar and oil slurry), and produced water, which resulted in a pH of7.05. Prior to addition of the 80% acetic acid solution, the pH of theother components was 7.42.

These embodiments are preferably used with fracturing fluids having TDSlevels in the range of about 1,500 ppm to 400,000 ppm and mostpreferably in the range of about 5,000 ppm to 200,000 ppm or in waterswhere the precipitation of water hardness (such as from calcium ormagnesium) significantly reduce the stability of the boron crosslink dueto the precipitation of commonly used high pH buffers such as hydroxideand/or carbonate based buffers. Such fracturing fluids preferablycontain calcium levels in excess of about 500 ppm and/or magnesiumlevels in excess of about 150 ppm. The required pH level to maintain astable crosslink between the preferred guar gum polymer and boroncrosslinker can vary depending on the temperature, level of TDS, andother factors, but a pH of between 9.0 and 12.0 is preferred. To achievethese pH levels and maintain a stable level at elevated bottom holetemperatures with high TDS fluids, it is preferred that about 0.41 pptto about 65.22 ppt, and most preferably about 3 ppt to about 11 ppt, ofthe crosslinking agent is used. When boric acid is used as thecrosslinking agent, the preferred amount of boric acid used is about 4ppt to about 11 ppt, and most preferably from about 4.4 ppt to about 10ppt. Most preferably, the concentration of amine pH buffer used is about0.5 gpt to about 10 gpt. It is also preferred that about 5 ppt to about100 ppt polymer is used. Most preferably, the concentration of polymerused is about 10 ppt to about 50 ppt. The compositions of the inventionpreferably have certain ratios of amine pH buffer to crosslinker and ofpolymer to crosslinker to achieve stable crosslinking in highTDS/hardness conditions at elevated bottom-hole temperatures.Preferably, around 0.5 to 300 times as much amine pH buffer (by weight)is used relative to the amount of crosslinking agent used. Mostpreferably, the amount of amine pH buffer (by weight) used is around 3to 10 times the amount of the crosslinking agent. It is also preferredthat 0.15 to 200 times as much polymer (by weight) is used relative tothe amount of crosslinking agent used. Most preferably, the amount ofpolymer (by weight) used is around 1 to 10 times the amount ofcrosslinking agents.

According to a preferred embodiment for using the preferred compositionaccording to the invention, the polymer is first added to the fracturingfluid, which contains water sources with high levels of TDS, such asproduced waters or mixtures of produced waters and fresh waters, tohydrate the polymer and form a gel. The preferred polymer is guar gum.Preferably, the fracturing fluid has a TDS level greater than 1,500 ppmand most preferably greater than 10,000 ppm, with calcium levels greaterthan 500 ppm and/or magnesium levels greater than 150 ppm. Thecompositions according to the invention are particularly well suited foruse with such fracturing fluids, but the compositions may also be usedwith fracturing fluids containing other levels of TDS, and specificallycalcium and/or magnesium levels which precipitate with conventionalhydroxide and/or carbonate buffers. Then a crosslinking agent, amine pHbuffer, and optionally a secondary pH buffer are added to the fracturingfluid containing the hydrated polymer. The crosslinking agent and aminepH buffer may be pre-mixed in a solution prior to adding to thefracturing fluid, with a secondary pH buffer and/or additional amine pHbuffer (which may further stabilize the crosslinked fluid) optionallyadded separately. Alternatively, the crosslinking agent and secondary pHbuffer may be pre-mixed in a solution prior to adding to the fracturingfluid, with the amine pH buffer added separately. As anotheralternative, the crosslinking agent, amine pH buffer, and secondary pHbuffer (if used) may all be added to the fracturing fluid separately.Water and other agents, such as freeze point depressors, may also bemixed with any of these components or may added to these solutions priorto adding to the fracturing fluid.

When pre-mixed, the crosslinker-amine buffer solution preferablycomprises between 2% to 50% by weight of a crosslinking agent, which ispreferably a boron compound such as boric acid, and between 1% to 70% byweight of an amine high pH buffer, although this percentage could be ashigh as 95% by weight when a pure form of an amine high pH buffer (suchas pure DETA) is used. Most preferably, the crosslinker-buffer solutioncomprises between 8%-10% by weight of a cross-linking agent and around48% to 52% by weight of an amine pH buffer. The amounts of crosslinkerand high pH buffer(s) used to achieve the desired crosslinked viscosityin the resulting fracturing fluid will vary depending on the hardness ofthe water and bottom-hole temperature, as will be apparent to those ofskill in the art.

When a secondary pH buffer or modifier, such as potassium hydroxide,sodium hydroxide, ammonium hydroxide, potassium carbonate, or mixturesthereof is used, the crosslinker-buffer solution preferably has between2% to 30% by weight of a crosslinking agent, 1% to 70% by weight of anamine pH buffer (although this percentage be as high as 90% by weightwhen a pure form of an amine high pH buffer, such as pure DETA, isused), and 0.1% to 50% by weight (total) of one or more secondary pHbuffers or modifiers. Alternatively, the crosslinking agent and thesecondary pH buffer may be mixed into a solution that is subsequentlymixed with the alkylamine buffer either prior to addition to thefracturing fluid containing the hydrated polymer or as components addedseparately to the fracturing fluid containing the hydrated polymer.Plexbor 101, commercially available from Chemplex Advanced Materials,LLC, is a preferred crosslinking agent-secondary buffer solution,containing boric acid pre-mixed with potassium hydroxide, and water.When using Plexbor or a similar pre-mixed crosslinker-secondary buffersolution, preferably about 0.25 gpt to about 20 gpt, and more preferablyabout 0.25 gpt to about 10 gpt is used. The amounts of crosslinker,amine pH buffer(s), and secondary pH buffer(s) (if any) used to achievethe desired crosslinked viscosity in the resulting fracturing fluid willvary depending on the hardness of the water and bottom-hole temperature,as will be apparent to those of skill in the art.

Adding the polymer to the fracturing fluid first and then adding thecrosslinker-buffer solution (either with or without a second pH buffer)has the advantage of allowing the polymer to be hydrated by thefracturing fluid to form a gel. The polymer will not hydrate or will bedelayed in hydration in the presence of a boron crosslinking agent at analkaline pH, so it is best to avoid adding the alkylamine pH buffer (andany secondary high pH buffer or modifier) until after the polymer hashydrated. Although it is preferred to pre-mix the crosslinker-buffersolution and add it to the fracturing fluid after the polymer hashydrated, a crosslinking agent that crosslinks at an alkaline pH couldbe added to the fracturing fluid at the same time as the polymer,provided the overall pH of the fluid is near neutral or acidic topromote hydration, and the amine buffer and any optional secondary pHbuffer or modifier added later. The order of addition of the componentsto the fracturing fluid is not critical provided that the polymer ishydrated before being introduced to the crosslinker at a pH level thatwould hinder hydration.

Several treatment compositions containing various concentrations of thepreferred components (guar, boric acid, and DETA) were prepared andtested for viscosity in timed intervals over 60 minutes. Table 1 belowshows the components in the compositions tested in gpt (gallons perthousand gallons of fluid, including the fracturing fluid). A producedwater sample was used as the fracturing fluid in each test. Wateranalysis of the produced water indicated it had a specific gravity of1.080, a pH of 7.12, no H₂S was detected, and a total dissolved solidsof 109,534 mg/l. The water analysis data for specific dissolved mineralsin the produced water are shown in Table 2.

TABLE 1 Boric Acid & Low pH Secondary pH Hydration Guar Slurry BufferSolution DETA Biocide Enhancer Test No. (gpt) (gpt) (gpt) (gpt) (gpt) 15 2 1 0.5 0.05 2 5 2 2 0.5 0.05 3 5 2.5 2 0.5 0.05 4 5 2.5 2.5 0.5 0.055 5 3 2.5 0.5 0.05 6 5 2.5 3 0.5 0.05

TABLE 2 Amount Measured Mineral Component (mg/L) Sodium (calculated)38,269 Calcium 2,800 Magnesium 972 Iron 10 Chloride 66,310 Sulfate 320Bicarbonate 854 TDS (Total Dissolved 109,534 Solids)

In these tests, a guar slurry was first added to the produced waters andwas blended for 60 minutes to allow the guar to hydrate and form a gel.Then the boric acid and secondary pH buffer solution and DETA weresimultaneously added to the produced waters containing the hydrated guarand the entire mixture blended for 30 seconds or until the fluidcrosslinked. Once all the components were added, the fluid was thenplaced in a high temperature high pressure (HTHP) viscometer and thetemperature increased from ambient temperature to 146° F. in the firstfifteen minutes and held constant at 146° F. for the remainder of thetest. This simulates use of the composition in a typical downholeenvironment, although the compositions according to the invention areuseful over a wider temperature range from about 80° F. to about 250° F.The biocide and hydration enhancer were added to the produced waterswith the guar slurry, as it is generally preferred to add theseadditives to the fracturing fluid at an early stage of the process, butthe timing and sequence of addition of these optional additives is notcritical to the functioning of the compositions according to theinvention.

The guar slurry used in these tests comprises guar suspended in asemi-synthetic oil at a concentration of four pounds of guar per gallonof slurry. This slurry is commercially available as Plexgel 907LEB fromChemplex Advanced Materials, LLC. When the slurry is added to theproduced water, it is hydrated and forms a viscous gel. The crosslinkingagent used in these tests is a boric acid pre-mixed with a secondary pHbuffer, potassium hydroxide, and water. This solution is commerciallyavailable as Plexbor 101 from Chemplex Advanced Materials, LLC. Thebiocide and hydration enhancer used are commercially available asPlexicide 24L and Acetiplex 80 (and 80% acetic acid solution),respectively, from Chemplex Advanced Materials, LLC. The biocide andhydration enhancer are usually helpful additives for fracturingoperations, but are not necessary to achieve stable crosslinking in thepresence of high TDS levels at bottom hole temperatures.

Table 3 below shows the viscosity in centipoise at 40/sec for each ofthe compositions tested at five minute intervals over the 60 minuteperiod. FIG. 1 shows the viscosity over the 60 minute test period ingraphical form.

TABLE 3 Test Time Temp. Test 1 Test 2 Test 3 Test 4 Test 5 6 (min.) (°F.) (cp) (cp) (cp) (cp) (cp) (cp) 5 120 547 609 622 669 618 495 10 143394 490 495 676 595 600 15 146 391 544 513 637 528 611 20 146 348 516495 648 489 547 25 146 316 505 513 588 432 515 30 146 287 487 507 661427 552 35 146 251 480 515 618 419 566 40 146 224 471 507 611 425 536 45146 217 465 495 627 438 555 50 146 196 468 483 606 436 566 55 146 168465 489 621 463 587 60 146 163 465 521 613 430 560

The viscosity measurements indicate the stability of the crosslinkbetween the guar and boron from the boric acid in the presence of highTDS, including high levels of both calcium and magnesium, at an elevatedtemperature of 146° F. with the use of DETA as a high pH amine buffer.Whereas if the pH does not remain greater than about 9.0 at abottom-hole test temperature of 146° F., the crosslinking would bereversed (uncrosslink) and the viscosity would drop to less than 50 cp.If the pH remains greater than about 9.0 under the same conditions, thecrosslinking is stable and the viscosity will remain at an acceptablyhigh level. It is preferred that at a given polymer loading, thecrosslink viscosity be optimized with respect to viscosity which resultswhen proper dosages of boron crosslinkers and stable high pH levels areachieved and maintained through the duration of the test and fracturetreatment at the bottom-hole temperature. Typical optimized crosslinkviscosity levels from Table 3 ranged from about 430 cp to about 560 cpat 60 minutes at 146 F and are considered acceptable for fracturingoperations, while levels less than 200 cp are not generally consideredideal. There are some fluctuations in the viscosity readings, which areto be expected as the composition continues to be mixed together in theproduced water as it was blended. As demonstrated by the results inTable 3 and as illustrated in FIG. 1, the readings for Examples 2-6 showstable viscosity levels indicating stable crosslinking and range from aninitial viscosity of 669 cp to 430 cp at 60 minutes. Only Test 1indicated unstable crosslinking by a significant decline in viscositylevel from an initial reading of 547 cp to a final 60 minute reading of163 cp. The composition used in Test 1 had the least amount of DETA,only 1 gpt, compared to 2 to 3 gpt in the other test compositions.

The concentrations of DETA and boric acid in Test 1 were 1 gpt 2 gpt ofthe overall fluid (including the produced water), respectively, which isbelow the preferred ratio of the amount of DETA which is 3 times (ormore) than the boric acid (by weight) for compositions according to theinvention. The amounts of DETA and boric acid in each of Tests 2-6 arewithin the preferred ratio for an optimized and stable boron crosslinkat 146° F. according to the invention. Tests 4 and 6 had the highestviscosity readings. The amounts of DETA and Plexbor 101 in Test 4 were2.5 gpt and 2.5 gpt of the overall fluid (including the produced water),respectively. Additionally, the amount of Plexgel 907LEB in Test 4 was 5gpt or 20 ppt guar polymer. The amounts of DETA and Plexbor 101 in Test6 were 3 gpt and 2.5 gpt of the overall fluid (including the producedwater), respectively. Additionally, the amount of Plexgel 907LEB in Test6 was 5 gpt or 20 ppt guar polymer. These tests demonstrate thatcompositions having the preferred relative amounts of polymer,crosslinking agent, and pH buffer according to the invention are capableof maintaining a stable pH level, and stable viscosity level, atelevated temperatures in the presence high total dissolved solids in thefracturing fluid.

Another set of tests were run with a different produced water sample andat a temperature of 196° F. Table 4 below shows the components in thecompositions tested in gpt (gallons per thousand gallons of fluid,including the fracturing fluid). Water analysis of the produced waterused in these tests indicated it had a specific gravity of 1.080, a pHof 6.17, no H₂S was detected, and a total dissolved solids of 112,682mg/l. The water analysis data for specific dissolved minerals in theproduced water are shown in Table 5.

TABLE 4 Boric Acid & Low pH Secondary pH Hydration Guar Slurry BufferSolution DETA Biocide Enhancer Test No. (gpt) (gpt) (gpt) (gpt) (gpt) 77.5 4 5 0.5 0.05 8 7.5 4 4 0.5 0.05 9 7.5 4 3.5 0.5 0.05 10 7.5 4 3 0.50.05 11 7.5 3.5 3.5 0.5 0.05

TABLE 5 Amount Measured Mineral Component (mg/L) Sodium (calculated)39,629 Calcium 1,920 Magnesium 1,567 Iron 25 Chloride 68,792 Sulfate 468Bicarbonate 305 TDS (Total Dissolved 112,682 Solids)

The guar slurry, biocide, hydration enhancer, crosslinker-buffersolution and amine pH buffer used in these tests are the same as thoseused for Test Nos. 1-6. The mixing procedures were also the same and thetemperature increased from ambient temperature to 196° F. within thefirst 15 minutes to simulate bottom-hole temperatures. Table 6 belowshows the viscosity in centipoise at 40/sec for each of the compositionstested at five minute intervals over the 60 minute period as measured ona high temperature high pressure (HTHP) viscometer. FIG. 2 shows theviscosity over the 60 minute test period in graphical form.

TABLE 6 Time Temp. Test 7 Test 8 Test 9 Test 10 Test 11 (min.) (° F.)(cp) (cp) (cp) (cp) (cp) 5 165 1120 961 862 837 818 10 192 850 780 821677 718 15 196 733 740 735 675 711 20 196 718 760 708 630 696 25 196 695708 679 609 684 30 196 662 708 707 609 660 35 196 695 704 679 600 656 40196 678 701 664 606 675 45 196 669 701 643 660 660 50 196 660 698 671629 672 55 196 654 692 678 587 665 60 196 683 682 701 635 638

The viscosity measurements indicate the stability of the crosslinkbetween the guar and boron from the boric acid in the presence of highTDS, including high levels of both calcium and magnesium, at an elevatedtemperature of 196° F. with the use of DETA as a high pH amine buffer.The concentration of DETA used in each of these tests was at least 3.0gpt and resulted in stable crosslinking, demonstrated by stableviscosity, at 196° F.

Additional tests were conducted using Plexbor 101 (boric acid andpotassium hydroxide pH buffer), the same guar slurry as the other tests,and high TDS produced water (containing high levels of calcium andmagnesium) as the fracturing fluid, but this time the DETA was omitted.The produced water samples used in these tests were the same as thoseused in the two previous sets of tests. The polymer did not crosslink inthese tests, demonstrating that boron crosslinkers and common buffersare not suitable for use with high TDS fracturing fluids without theaddition of an amine pH buffer.

Although test compositions for Test Nos. 2-11 are preferred compositionsaccording to the invention, other compositions may be used within thescope of the invention. Those of ordinary skill in the art willappreciate upon reading this specification, including the examplescontained herein, that modifications and alterations to the compositionand methodology for using the composition may be made within the scopeof the invention and it is intended that the scope of the inventiondisclosed herein be limited only by the broadest interpretation of theappended claims to which the inventor is legally entitled.

We claim:
 1. A treatment composition for increasing the viscosity of afracturing fluid, the composition comprising: a galactomannan polymer; aboron compound capable of crosslinking with the polymer; a pH buffercomprising an amine, the pH buffer capable of maintaining the pH of thecomposition in the fracturing fluid above 9.0 at temperatures greaterthan 80° F.; wherein the concentration of pH buffer is between 0.25 to30 gpt.
 2. The treatment composition of claim 1 further comprising asecondary pH buffer having an alkaline pH.
 3. The treatment compositionof claim 1 wherein the amount of pH buffer comprising an amine is atleast about 3 times the amount of boron compound, by weight.
 4. Thetreatment composition of claim 3 wherein the amount of galactomannanpolymer is at least about 3 times the amount of boron compound, byweight.
 5. The treatment composition of claim 1 wherein the polymer isguar gum and the boron compound is selected from the group consisting ofboric acid, borax, sodium borate, disodium tetraborate, sodiumtetraborate, sodium tetraborate decahydrate, amino boric acid, elluite,ulexite, colemanite, probertite, and mixtures thereof.
 6. The treatmentcomposition of claim 5 wherein the pH buffer is selected from the groupconsisting of n-butylamine, diethylenetriamine, diaminobutane,diethyldiamine, diisopropylamine, dodecylamine, ethylamine,ethylenediamine, di-(gamma-aminopropylether), methyleneamine,piperazine, triethylenetetramine, tetraethylenepentamine, triethylamine,amino diols, glycols poly glycols, and mixtures thereof.
 7. Thetreatment composition of claim 1 wherein the fracturing fluid comprisesproduced water.
 8. The treatment composition of claim 7 wherein thefracturing fluid comprises greater than 1,500 ppm total dissolvedsolids.
 9. The treatment composition of claim 7 wherein the fracturingfluid comprises greater than 10,000 ppm total dissolved solids.
 10. Thetreatment composition of claim 7 wherein the fracturing fluid comprisesgreater than 100,000 ppm total dissolved solids.
 11. The treatmentcomposition of claim 7 wherein the fracturing fluid water comprisescalcium levels greater than about 500 ppm or magnesium levels greaterthan about 150 ppm.
 12. The treatment composition of claim 11 whereinthe polymer is guar gum and the pH buffer is DETA.
 13. A fracturingfluid comprising: a liquid comprising greater than 1,500 ppm totaldissolved solids; a polymer soluble in the liquid; a boron crosslinkingagent capable of increasing the viscosity of the fracturing fluid bycrosslinking with the polymer; a pH buffer comprising an amine, the pHbuffer capable of maintaining the pH of the fracturing fluid above 9.0at temperatures greater than 80° F.
 14. The fracturing fluid of claim 13comprising about 5 to 100 ppt polymer, 0.25 to 20 gpt boron crosslinkingagent, and 0.25 to 30 gpt pH buffer.
 15. The fracturing fluid of claim14 wherein the polymer is a galactomannan polymer and the pH buffer isan alkylamine, and wherein the amount of alkylamine used is at least 3times the amount of boron crosslinking agent, by weight.
 16. Thefracturing fluid of claim 13 wherein the pH buffer is capable ofmaintaining the pH of the fracturing fluid above 9.0 at temperaturesgreater than 190° F.
 17. The fracturing fluid of claim 16 comprisingabout 7.6 to about 8.7 ppt boric acid and about 3.2 to about 4.6 gptamine pH buffer.
 18. A treatment composition for increasing theviscosity of a fracturing fluid, the composition comprising: apolysaccharide polymer; a boron compound capable of crosslinking withthe polymer; an alkylamine pH buffer capable of maintaining the pH ofthe composition in the fracturing fluid above 9.0 at temperaturesgreater than 80° F.; wherein the amount of alkylamine is at least about3 times the amount of boron compound and the amount of polymer is atleast about 3 times the amount of boron compound, by weight.
 19. Thetreatment composition of claim 18 wherein the polymer is a slurry ofguar gum and oil comprising about 3 to 5 pounds of guar per gallon ofslurry.
 20. The treatment composition of claim 19 wherein the alkylamineis DETA and the boron compound is boric acid.
 21. The treatmentcomposition of claim 20 wherein the fracturing fluid comprises producedwater and has calcium levels greater than about 500 ppm or magnesiumlevels greater than about 150 ppm.
 22. The treatment composition ofclaim 21 comprising about 4 to 6 gpt polymer slurry, about 4.3 to 7 pptboric acid, and about 0.5 to 3.5 gpt alkylamine.
 23. The treatmentcomposition of claim 18 comprising about 30 to 40 ppt polysaccharidepolymer, about 4.3 to 7 ppt boron compound, and about 3.2 to about 4.6gpt alkylamine buffer; and wherein the polysaccharide polymer is guargum and the boron compound is boric acid.
 24. A method of treating afracturing fluid to maintain a stable crosslink viscosity, the methodcomprising: providing a fracturing fluid comprising produced waters andhaving a total dissolved solids level greater than 1,500 ppm; adding apolysaccharide to the fracturing fluid to hydrate the polysaccharide;adding an alkylamine pH buffer to the fracturing the fluid, thealkylamine pH buffer being capable of maintaining the fracturing fluidat a pH level greater than 9.0 at temperatures greater than about 80°F.; adding a boron crosslinking compound to the fracturing fluid;wherein the alkylamine pH buffer is not added until after thepolysaccharide has had sufficient time to hydrate in the fracturingfluid.
 25. The method of claim 24 wherein the polysaccharide is mixedwith oil to form a slurry comprising about 3-5 pounds of polysaccharideper gallon of slurry prior to adding to the fracturing fluid.
 26. Themethod of claim 25 wherein about 4 to 6 gpt polysaccharide slurry, about0.4 to 0.6 gpt boron compound, and about 0.5 to 3.5 gpt alkylamine areadded to the fracturing fluid.
 27. The method of claim 25 wherein theboron crosslinking compound is mixed with a secondary pH buffer havingan alkaline pH to form a crosslinker-buffer solution prior to adding tothe fracturing fluid.
 28. The method of claim 27 wherein about 4 to 6gpt polysaccharide slurry, about 1.5 to 4 gpt crosslinker-buffersolution, and about 0.5 to 3.5 gpt alkylamine are added to thefracturing fluid.